Integrated process for oil extraction and production of diesel fuel from biorenewable feedstocks

ABSTRACT

An integrated process has been developed for producing diesel boiling range fuel from renewable feedstocks such as animal and plant oils and using a byproduct naphtha as an extraction solvent in the generation of the renewable feedstock. The process involves treating a renewable feedstock by hydrogenating and deoxygenating to provide a hydrocarbon fraction useful as a diesel fuel or diesel boiling range fuel blending component. A byproduct naphtha stream is used as an extraction solvent in a process for the generation of the renewable feedstock. If desired, the hydrocarbon fraction can be isomerized to improve cold flow properties.

CROSS-REFERENCE TO RELATED APPLICATION

This application claims priority from Provisional Application Ser. No.60/973,812 filed Sep. 20, 2007, the contents of which are herebyincorporated by reference in its entirety.

FIELD OF THE INVENTION

This invention relates to an integrated process for producinghydrocarbons useful as diesel boiling range fuel from renewablefeedstocks such as the glycerides and free fatty acids found inmaterials such as plant oils, fish oils, animal fats, and greases, andan oil extraction process to extract the renewable feedstock from itssource. The diesel boiling range fuel production portion of the processinvolves hydrogenation, decarboxylation and/or hydrodeoxygenation andoptional isomerization in one or more reactors. Naphtha is separatedfrom the hydrocarbon product of the diesel boiling range fuel productionprocess and is used as an extraction solvent in an oil extractionprocess.

BACKGROUND OF THE INVENTION

As the demand for diesel boiling range fuel increases worldwide there isincreasing interest in sources other than petroleum crude oil forproducing diesel boiling range fuel. One such renewable source is whathas been termed renewable sources. These renewable sources include, butare not limited to, plant oils such as corn, rapeseed, canola, soybeanand algal oils, animal fats such as inedible tallow, fish oils andvarious waste streams such as yellow and brown greases and sewagesludge. The common feature of these sources is that they are composed ofglycerides and Free Fatty Acids (FFA). Both of these classes ofcompounds contain aliphatic carbon chains having from about 8 to about24 carbon atoms. Most of the aliphatic chains in the glycerides or FFAscan be fully saturated, or mono, di or poly-unsaturated.

There are reports in the art disclosing the production of hydrocarbonsfrom oils. For example, U.S. Pat. No. 4,300,009 discloses the use ofcrystalline aluminosilicate zeolites to convert plant oils such as cornoil to hydrocarbons such as gasoline and chemicals such as para-xylene.U.S. Pat. No. 4,992,605 discloses the production of hydrocarbon productsin the diesel boiling range by hydroprocessing vegetable oils such ascanola or sunflower oil. Finally, US 2004/0230085 A1 discloses a processfor treating a hydrocarbon component of biological origin byhydrodeoxygenation followed by isomerization.

Applicants have developed a process which integrates an oil extractionprocess with the generation of diesel boiling range fuel, or fuelblending component from a renewable feedstock. The diesel boiling rangefuel production process comprises one or more steps to hydrogenate,decarboxylate, decarbonylate (and/or hydrodeoxygenate) and optionallyisomerize the renewable feedstock. Naphtha is separated from thehydrocarbon product of the reaction zones. The naphtha is used as anextraction solvent in a process to extract the renewable feedstock oilsor fats from the source of the oils or fats.

SUMMARY OF THE INVENTION

An integrated process to extract a renewable feedstock from a source toand produce a paraffin-rich diesel boiling range product from therenewable feedstock wherein the process comprises treating the renewablefeedstock in a reaction zone by hydrogenating and deoxygenating thefeedstock at reaction conditions to provide a first reaction productcomprising a hydrocarbon fraction comprising paraffins, separating anaphtha fraction from the hydrocarbon fraction and utilizing theseparated naphtha fraction as an extraction solvent in an extractionprocess to generate the renewable feedstock.

BRIEF DESCRIPTION OF THE DRAWINGS

FIG. 1 and FIG. 2 are schematics of one embodiment of the invention.FIG. 1 is a more simplistic schematic, while FIG. 2 is more detailed.

DETAILED DESCRIPTION OF THE INVENTION

As stated, the present invention integrates a process for producing ahydrocarbon stream useful at least as diesel boiling range fuel or fuelblending component from renewable feedstocks such as renewablefeedstocks originating from plants or animals and a process forpreparing such feedstocks from their source materials. The termrenewable feedstock is meant to include feedstocks other than thoseobtained from petroleum crude oil. Another term that has been used todescribe this class of feedstock is biorenewable fats and oils. Therenewable feedstocks that can be used in the present invention includeany of those which comprise glycerides and free fatty acids (FFA). Mostof the glycerides will be triglycerides, but monoglycerides anddiglycerides may be present and processed as well. Examples of theserenewable feedstocks include, but are not limited to, canola oil, cornoil, soy oils, rapeseed oil, soybean oil, colza oil, tall oil, sunfloweroil, hempseed oil, olive oil, linseed oil, coconut oil, castor oil,peanut oil, palm oil, mustard oil, cottonseed oil, jatropha oil, tallow,yellow and brown greases, lard, train oil, fats in milk, fish oil, algaloil, sewage sludge, and the like. Additional examples of renewablefeedstocks include non-edible vegetable oils from the group comprisingJatropha curcas (Ratanjoy, Wild Castor, Jangli Erandi), Madhuca indica(Mohuwa), Pongamia pinnata (Karanji Honge), and Azadiracta indicia(Neem). The triglycerides and FFAs of the typical vegetable or animalfat contain aliphatic hydrocarbon chains in their structure which haveabout 8 to about 24 carbon atoms with a majority of the fats and oilscontaining high concentrations of fatty acids with 16 and 18 carbonatoms. Mixtures or co-feeds of renewable feedstocks and petroleumderived hydrocarbons may also be used as the feedstock. Other feedstockcomponents which may be used, especially as a co-feed component incombination with the above listed feedstocks, include spent motor oilsand industrial lubricants, used paraffin waxes, liquids derived from thegasification of coal, biomass, or natural gas followed by a downstreamliquefaction step such as Fischer-Tropsch technology, liquids derivedfrom depolymerization, thermal or chemical, of waste plastics such aspolypropylene, high density polyethylene, and low density polyethylene;and other synthetic oils generated as byproducts from petrochemical andchemical processes. Mixtures of the above feedstocks may also be used asco-feed components. One advantage of using a co-feed component is thetransformation of what has been considered to be a waste product from apetroleum based or other process into a valuable co-feed component tothe current process.

Renewable feedstocks such as those above are prepared by varioustechniques known in the art. Often the preparation involves extractionof the fats or oils from the source material. The source material isoften a solid such as seeds or beans or animal material, and the oilsand fats need to be separated from the solid material in order to beused as a feedstock. Typical steps to prepare the feedstock may includeacts such as cleaning the source material, conditioning, flaking orgrinding, heating the material, pressing, extracting, and removing thesolvent. Many extractions processes are commercially available andhexane is a common extraction solvent. Examples of current commercialextractors include percolation type extractors or immersion typeextractors. The source material may be soaked or solvent washed instages, first with hexane already high in oil or fat content (miscella)and then with progressively leaner miscella and finally with justhexane. After extraction, the miscella may be filtered to remove finesand stripped of the extraction solvent. Examples of oil extraction andprocessing include Hui, Y. H, Baileys Industrial Oil and Fats Products,Vol. 2, pp. 19-20, and the like.

The integration of the feedstock generation process and the dieselboiling range fuel generation process centers around the need for asolvent in the extraction step of the feedstock generation and thebyproduct naphtha produced in the diesel fuel generation process. Hexanehas been a traditional solvent in known extraction processes. Thenaphtha generated as a byproduct in the production of diesel boilingrange fuel from renewable feedstocks typically contains paraffinichydrocarbons having boiling points in the range of 30 to 170° C. andhaving from about 5 to about 7 carbon atoms. The naphtha stream may beused as all or part of the extraction solvent in the extraction process.In this way, a byproduct in one process becomes the source of anotherwise expensive solvent in a related process.

Turning to the diesel fuel generation portion of the integrated process,renewable feedstocks that can be used as the feedstock to the dieselboiling range fuel generation process may contain a variety ofimpurities. For example, tall oil is a byproduct of the wood processingindustry and tall oil contains esters and rosin acids in addition toFFAs. Rosin acids are cyclic carboxylic acids. The renewable feedstocksmay also contain contaminants such as alkali metals, e.g. sodium andpotassium, phosphorous as well as solids, water and detergents. Anoptional first step is to remove as much of these contaminants aspossible. One possible pretreatment step involves contacting therenewable feedstock with an ion-exchange resin in a pretreatment zone atpretreatment conditions. The ion-exchange resin is an acidic ionexchange resin such as Amberlyst™-15 and can be used as a bed in areactor through which the feedstock is flowed through, either upflow ordownflow. The conditions at which the reactor is operated are well knownin the art.

Another possible means for removing contaminants is a mild acid wash.This is carried out by contacting the feedstock with an acid such assulfuric, nitric or hydrochloric acid in a reactor. The acid andfeedstock can be contacted either in a batch or continuous process.Contacting is done with a dilute acid solution usually at ambienttemperature and atmospheric pressure. If the contacting is done in acontinuous manner, it is usually done in a counter current manner. Yetanother possible means of removing metal contaminants from the feedstockis through the use of guard beds which are well known in the art. Thesecan include alumina guard beds either with or without demetallationcatalysts such as nickel or cobalt. Filtration and solvent extractiontechniques are other choices which may be employed. Hydroprocessing suchas that described in U.S. Ser. No. 11/770,826, hereby incorporated byreference, is another pretreatment technique which may be employed.

The renewable feedstock is flowed to a first reaction zone comprisingone or more catalyst beds in one or more reactors. The term “feedstock”is meant to include feedstocks that have not been treated to removecontaminants as well as those feedstocks purified in a pretreatmentzone. In the reaction first zone, the feedstock is contacted with ahydrogenation or hydrotreating catalyst in the presence of hydrogen athydrogenation conditions to hydrogenate the olefinic or unsaturatedportions of the aliphatic side chains of the glyceride molecules.Hydrogenation or hydrotreating catalysts are any of those well known inthe art such as nickel or nickel/molybdenum dispersed on a high surfacearea support. Other hydrogenation catalysts include one or more noblemetal catalytic elements dispersed on a high surface area support.Non-limiting examples of noble metals include Pt and/or Pd dispersed ongamma-alumina. Hydrogenation conditions include a temperature of about40° C. to about 400° C. and a pressure of about 689 kPa absolute (100psia) to about 13,790 kPa absolute (2000 psia). In another embodimentthe hydrogenation conditions include a temperature of about 200° C. toabout 300° C. and a pressure of about 1379 kPa absolute (200 psia) toabout 4826 kPa absolute (700 psia). Other operating conditions for thehydrogenation zone are well known in the art.

The hydrogenation or hydrotreating catalysts enumerated above are alsocapable of catalyzing decarboxylation and/or hydrodeoxygenation of thefeedstock to remove oxygen. Decarboxylation, decarbonylation, andhydrodeoxygenation are herein collectively referred to as deoxygenationreactions. Decarboxylation conditions include a relatively low pressureof about 3447 kPa (500 psia) to about 6895 kPa (1000 psia), atemperature of about 200° C. to about 400° C. and a liquid hourly spacevelocity of about 0.5 to about 10 hr⁻¹. In another embodiment thedecarboxylation conditions include the same relatively low pressure ofabout 3447 kPa (500 psia) to about 6895 kPa (1000 psia), a temperatureof about 288° C. to about 345° C. and a liquid hourly space velocity ofabout 1 to about 4 hr⁻¹. Since hydrogenation is an exothermic reaction,as the feedstock flows through the catalyst bed the temperatureincreases and decarboxylation and hydrodeoxygenation will begin tooccur. Thus, it is envisioned and is within the scope of this inventionthat all of the reactions occur simultaneously in one reactor or in onebed. Alternatively, the conditions can be controlled such thathydrogenation primarily occurs in one bed and decarboxylation and/orhydrodeoxygenation occurs in a second bed. Of course if only one bed isused, then hydrogenation may occur primarily at the front of the bed,while deoxygenation occurs mainly in the middle and bottom of the bed.Finally, desired hydrogenation can be carried out in one reactor, whiledeoxygenation can be carried out in a separate reactor.

The reaction product from the hydrogenation and deoxygenation reactionswill comprise a liquid portion and a gaseous portion. The liquid portioncomprises a hydrocarbon fraction which is essentially all n-paraffinsand having a large concentration of paraffins in the range of about 9 toabout 18 carbon atoms. Different feedstocks will result in differentdistributions of paraffins. The gaseous portion comprises hydrogen,carbon dioxide, carbon monoxide, water vapor, propane and perhaps sulfurcomponents such as hydrogen sulfide or phosphorous component such asphosphine.

In one embodiment, the effluent from the deoxygenation reactor isconducted to an optional hot high pressure hydrogen stripper. Onepurpose of the hot high pressure hydrogen stripper is to separate thegaseous portion of the effluent from the liquid portion of the effluent.As hydrogen is an expensive resource, to conserve costs, the separatedhydrogen is recycled to the first reaction zone containing thedeoxygenation reactor. Also, failure to remove the water, carbonmonoxide, and carbon dioxide from the effluent may result in poorcatalyst performance in the isomerization zone. Water, carbon monoxide,carbon dioxide, any ammonia or hydrogen sulfide are selectively strippedin the hot high pressure hydrogen stripper using hydrogen. Thetemperature may be controlled in a limited range to achieve the desiredseparation and the pressure may be maintain at approximately the samepressure as the two reaction zones to minimize both investment andoperating costs. The hot high pressure hydrogen stripper may be operatedat conditions ranging from a pressure of about 689 kPa absolute (100psia) to about 13,790 kPa absolute (2000 psia), and a temperature ofabout 40° C. to about 350° C. In another embodiment the hot highpressure hydrogen stripper may be operated at conditions ranging from apressure of about 1379 kPa absolute (200 psia) to about 4826 kPaabsolute (700 psia), or about 2413 kPa absolute (350 psia) to about 4882kPa absolute (650 psia), and a temperature of about 50° C. to about 350°C.

The effluent enters the optional hot high pressure stripper and thegaseous components, are carried with the hydrogen stripping gas andseparated into an overhead stream. Additional hydrogen is used as thestripping gas. The remainder of the deoxygenation effluent stream isremoved as hot high pressure hydrogen stripper bottoms and contains theliquid hydrocarbon fraction having components such as normalhydrocarbons having from about 8 to about 24 carbon atoms. A portion ofthis liquid hydrocarbon fraction in hot high pressure hydrogen stripperbottoms may be used as the hydrocarbon recycle described below.

Hydrogen is a reactant in at least some of the reactions above, and tobe effective, a sufficient quantity of hydrogen must be in solution tomost effectively take part in the catalytic reaction. Past processeshave operated at high pressures in order to achieve a desired amount ofhydrogen in solution and readily available for reaction. However, higherpressure operations are more costly to build and to operate as comparedto their lower pressure counterparts. One advantage of the presentinvention is the operating pressure may be in the range of about 1379kPa absolute (200 psia) to about 4826 kPa absolute (700 psia) which islower than that found in other previous operations. In anotherembodiment the operating pressure is in the range of about 2413 kPaabsolute (350 psia) to about 4481 kPa absolute (650 psia), and in yetanother embodiment operating pressure is in the range of about 2758 kPaabsolute (400 psia) to about 4137 kPa absolute (600 psia). Furthermore,the rate of reaction is increased resulting in a greater amount ofthroughput of material through the reactor in a given period of time.

In one embodiment, the desired amount of hydrogen is kept in solution atlower pressures by employing a large recycle of hydrocarbon. Otherprocesses have employed hydrocarbon recycle in order to control thetemperature in the reaction zones since the reactions are exothermicreactions. However, the range of recycle to feedstock ratios used hereinis determined not on temperature control requirements, but instead,based upon hydrogen solubility requirements. Hydrogen has a greatersolubility in the hydrocarbon product than it does in the feedstock. Byutilizing a large hydrocarbon recycle the solubility of hydrogen in theliquid phase in the reaction zone is greatly increased and higherpressures are not needed to increase the amount of hydrogen in solution.In one embodiment of the invention, the volume ratio of hydrocarbonrecycle to feedstock is from about 2:1 to about 8:1 or about 2:1 toabout 6:1. In another embodiment the ratio is in the range of about 3:1to about 6:1 and in yet another embodiment the ratio is in the range ofabout 4:1 to about 5:1.

Although this hydrocarbon fraction is useful as a diesel boiling rangefuel, or fuel blending component, because it comprises essentiallyn-paraffins, it will have poor cold flow properties. If it is desired toimprove the cold flow properties of the liquid hydrocarbon fraction,then the hydrocarbon fraction may be contacted with an isomerizationcatalyst under isomerization conditions to at least partially isomerizethe n-paraffins to branched paraffins. The effluent of the optionalsecond reaction zone, the isomerization zone, is abranched-paraffin-rich stream. By the term “rich” it is meant that theeffluent stream has a greater concentration of branched paraffins thanthe stream entering the isomerization zone, and preferably comprisesgreater than 50 mass-% branched paraffins. It is envisioned that theisomerization zone effluent may contains 70, 80, or 90 mass-% branchedparaffins. Isomerization can be carried out in a separate bed of thesame reaction zone, i.e. same reactor, described above or theisomerization can be carried out in a separate reactor. For ease ofdescription the following will address the embodiment where a secondreactor is employed for the isomerization reaction. The hydrocarbonstream is contacted with an isomerization catalyst in the presence ofhydrogen at isomerization conditions to isomerize the normal paraffinsto branched paraffins. Only minimal branching is required, enough toovercome the cold-flow problems of the normal paraffins. Sinceattempting for significant branching runs the risk of high degree ofundesired cracking, the predominant isomerized product is amono-branched hydrocarbon.

The hydrogen stripped product of the deoxygenation reaction zone iscontacted with an isomerization catalyst in the presence of hydrogen atisomerization conditions to isomerize the normal paraffins to branchedparaffins. Only minimal branching is required, enough to overcomecold-flow problems of the normal paraffins. Since attempting forsignificant branching runs the risk of high degree of undesiredcracking, the predominant isomerized product is a mono-branchedhydrocarbon.

The isomerization of the paraffinic product can be accomplished in anymanner known in the art or by using any suitable catalyst known in theart. One or more beds of catalyst may be used. It is preferred that theisomerization be operated in a co-current mode of operation. Fixed bed,trickle bed down flow or fixed bed liquid filled up-flow modes are bothsuitable. See also, for example, US 2004/0230085 A1 which isincorporated by reference in its entirety. Suitable catalysts comprise ametal of Group VIII (IUPAC 8-10) of the Periodic Table and a supportmaterial. Suitable Group VIII metals include platinum and palladium,each of which may be used alone or in combination. The support materialmay be amorphous or crystalline. Suitable support materials includeamorphous alumina, amorphous silica-alumina, ferrierite, ALPO-31,SAPO-11, SAPO-31, SAPO-37, SAPO-41, SM-3, MgAPSO-31, FU-9, NU-10, NU-23,ZSM-12, ZSM-22, ZSM-23, ZSM-35, ZSM48, ZSM-50, ZSM-57, MeAPO-11,MeAPO-31, MeAPO-41, MeAPSO-11, MeAPSO-31, MeAPSO-41, MeAPSO-46,ELAPO-11, ELAPO-31, ELAPO-41, ELAPSO-11, ELAPSO-31, ELAPSO-41,laumontite, cancrinite, offretite, hydrogen form of stillbite, magnesiumor calcium form of mordenite, and magnesium or calcium form ofpartheite, each of which may be used alone or in combination. ALPO-31 isdescribed in U.S. Pat. No. 4,310,440. SAPO-11, SAPO-31, SAPO-37, andSAPO-41 are described in U.S. Pat. No. 4,440,871. SM-3 is described inU.S. Pat. No. 4,943,424; U.S. Pat. No. 5,087,347; U.S. Pat. No.5,158,665; and U.S. Pat. No. 5,208,005. MgAPSO is a MeAPSO, which is anacronym for a metal aluminumsilicophosphate molecular sieve, where themetal Me is magnesium (Mg). Suitable MeAPSO-31 catalysts includeMgAPSO-31. MeAPSOs are described in U.S. Pat. No. 4,793,984, and MgAPSOsare described in U.S. Pat. No. 4,758,419. MgAPSO-31 is a preferredMgAPSO, where 31 means a MgAPSO having structure type 31. Many naturalzeolites, such as ferrierite, that have an initially reduced pore sizecan be converted to forms suitable for olefin skeletal isomerization byremoving associated alkali metal or alkaline earth metal by ammonium ionexchange and calcination to produce the substantially hydrogen form, astaught in U.S. Pat. No. 4,795,623 and U.S. Pat. No. 4,924,027. Furthercatalysts and conditions for skeletal isomerization are disclosed inU.S. Pat. No. 5,510,306, U.S. Pat. No. 5,082,956, and U.S. Pat. No.5,741,759.

The isomerization catalyst may also comprise a modifier selected fromthe group consisting of lanthanum, cerium, praseodymium, neodymium,samarium, gadolinium, terbium, and mixtures thereof, as described inU.S. Pat. No. 5,716,897 and U.S. Pat. No. 5,851,949. Other suitablesupport materials include ZSM-22, ZSM-23, and ZSM-35, which aredescribed for use in dewaxing in U.S. Pat. No. 5,246,566 and in thearticle entitled “New Molecular Sieve Process for Lube Dewaxing by WaxIsomerization,” written by S. J. Miller, in Microporous Materials 2(1994) 439-449. The teachings of U.S. Pat. No. 4,310,440; U.S. Pat. No.4,440,871; U.S. Pat. No. 4,793,984; U.S. Pat. No. 4,758,419; U.S. Pat.No. 4,943,424; U.S. Pat. No. 5,087,347; U.S. Pat. No. 5,158,665; U.S.Pat. No. 5,208,005; U.S. Pat. No. 5,246,566; U.S. Pat. No. 5,716,897;and U.S. Pat. No. 5,851,949 are hereby incorporated by reference.

U.S. Pat. No. 5,444,032 and U.S. Pat. No. 5,608,134 teach a suitablebifunctional catalyst which is constituted by an amorphoussilica-alumina gel and one or more metals belonging to Group VIIIA, andis effective in the hydroisomerization of long-chain normal paraffinscontaining more than 15 carbon atoms. U.S. Pat. No. 5,981,419 and U.S.Pat. No. 5,968,344 teach a suitable bifunctional catalyst whichcomprises: (a) a porous crystalline material isostructural withbeta-zeolite selected from boro-silicate (BOR-B) andboro-alumino-silicate (Al-BOR-B) in which the molar SiO₂Al₂O₃ ratio ishigher than 300:1; (b) one or more metal(s) belonging to Group VIIIA,selected from platinum and palladium, in an amount comprised within therange of from 0.05 to 5% by weight. Article V. Calemma et al., App.Catal. A: Gen., 190 (2000), 207 teaches yet another suitable catalyst.

The isomerization catalyst may be any of those well known in the artsuch as those described and cited above. Isomerization conditionsinclude a temperature of about 150° C. to about 360° C. and a pressureof about 1724 kPa absolute (250 psia) to about 4726 kPa absolute (700psia). In another embodiment the isomerization conditions include atemperature of about 300° C. to about 360° C. and a pressure of about3102 kPa absolute (450 psia) to about 3792 kPa absolute (550 psia).Other operating conditions for the isomerization zone are well known inthe art.

The final effluent stream which is at least the stream obtained afterall reactions have been carried out, is now processed through one ormore separation steps to obtain a purified hydrocarbon stream useful asa diesel fuel. Note that the final effluent stream may be the product ofthe deoxygenation reaction zone in the embodiment where the optionalisomerization is not preformed, or may be the product of thedeoxygenation reaction zone followed by the isomerization zone. Theoptional hot high pressure hydrogen stripper may or may not be employedafter the deoxygenation reaction zone. Therefore the final effluentstream may be the deoxygenation reaction zone product after separationin the hot high pressure hydrogen stripper. In the embodiment utilizingthe optional isomerization reaction zone, an optional isomerizationeffluent separator may be employed to separate and recycle a portion ofthe hydrogen. In this embodiment, the final effluent stream may be theisomerization reaction zone product after separation on theisomerization effluent separator.

With the final effluent stream comprising both a liquid component and agaseous component, various portions of which are to be recycled,multiple separation steps may be employed. For example, in theembodiment where the optional isomerization is employed, hydrogen isfirst separated in a isomerization effluent separator with the separatedhydrogen being removed in an overhead stream. Suitable operatingconditions of the isomerization effluent separator include, for example,a temperature of 230° C. and a pressure of 4100 kPa absolute (600 psia).If there is a low concentration of carbon oxides, or the carbon oxidesare removed, the hydrogen may be recycled back to the hot high pressurehydrogen stripper for use both as a stripping gas and to combine withthe remainder as a bottoms stream. The remainder is passed to theisomerization reaction zone and thus the hydrogen becomes a component ofthe isomerization reaction zone feed streams in order to provide thenecessary hydrogen partial pressures for the reactor. The hydrogen isalso a reactant in the oxygenation reactors, and different feedstockswill consume different amounts of hydrogen. The isomerization effluentseparator allows flexibility for the process to operate even when largeramounts of hydrogen are consumed in the first reaction zone.Furthermore, at least a portion of the remainder or bottoms stream ofthe isomerization effluent separator may be recycled to theisomerization reaction zone to increase the degree of isomerization.

The final effluent, even after the optional removal of hydrogen, stillhas liquid and gaseous components and is cooled, by techniques such asair cooling or water cooling and passed to a cold separator where theliquid component is separated from the gaseous component. Suitableoperating conditions of the cold separator include, for example, atemperature of about 20 to 60° C. and a pressure of 3850 kPa absolute(560 psia). A water byproduct stream is also separated. At least aportion of the liquid component, after cooling and separating from thegaseous component, may be optionally recycled back to the isomerizationzone to increase the degree of isomerization.

The liquid component contains the hydrocarbons useful as diesel fuel aswell as smaller amounts of naphtha and LPG. A portion of the separatedliquid component may be recovered as diesel fuel or the entire separatedliquid component may be further purified in a product stripper whichseparates lower boiling components and dissolved gases from the dieselproduct containing C₈ to C₂₄ normal and branched alkanes. Suitableoperating conditions of the product stripper include a temperate of fromabout 20 to about 200° C. at the overhead and a pressure from about 0 toabout 1379 kPa absolute (0 to 200 psia).

The LPG/Naphtha stream is further separated in a debutanizer ordepropanizer in order to separate the LPG into an overhead stream,leaving the naphtha in a bottoms stream. Suitable operating conditionsof this unit include a temperate of from about 20 to about 200° C. atthe overhead and a pressure from about 0 to about 2758 kPa absolute (0to 400 psia). The LPG may be sold as valuable product or may be used asfeed to a hydrogen production facility, or may be blended into thegasoline pool.

The separated naphtha is conducted to an oil extraction operation whichextracts oil usable as the renewable feedstock from a source material.The naphtha is used as the extraction solvent to extract the oil fromthe triglyceride rich oil bearing material. As discussed earlier,examples of oils include canola oil, corn oil, soy oils, rapeseed oil,soybean oil, colza oil, tall oil, sunflower oil, hempseed oil, oliveoil, linseed oil, coconut oil, castor oil, peanut oil, palm oil, mustardoil, cottonseed oil, jatropha oil, inedible tallow, yellow and browngreases, lard, train oil, fats in milk, fish oil, algal oil, and sewagesludge. As an example, soybean oil production involves several stepsthat are necessary to render the soybean oil suitable for a variety ofpurposes. These production steps may be broadly characterized as 1)soybean preparation, 2) oil extraction, and 3) oil refining. Oilextraction is for the purpose of separating the oil from the remainderof the soybean, known as soybean meal. In one process known asexpelling, the oil is extracted by passing the dehulled beans through ascrew press to crush the beans and separate the oil from the meal. Thegreat majority of commercial soybean extraction processes use a solventto separate the oil from the meal. In the solvent extraction process,the beans are flaked to provide a large surface area. A solvent,commonly hexane, is then pumped through the soybean flakes, dissolvingthe oil in the hexane. The hexane is then separated from the oil andrecycled.

Many such extraction processes are currently known, and any knownextraction process which traditionally employs hydrocarbons having fromabout 5 to about 12 carbon atoms, either singularly or in a mixture,such as pentane, hexane, cyclohexane, heptane, octane and or nonane asthe extraction solvent may integrated with the diesel fuel generationprocess as described herein. The separated naphtha is conducted to theextraction unit where the extraction solvent is employed. In this way, abyproduct stream of the diesel fuel generation process is integratedwith the process used to generate the renewable feedstock of the dieselfuel generation process. The naphtha stream is particularly suitable asthe extraction solvent since many oils are miscible with the naphthastream and the naphtha stream has a low viscosity. Furthermore, in oneembodiment, it is not necessary to separate the naphtha stream, afterbeing used as an extraction solvent, from the extracted oil. The mixturemay be introduced to a diesel boiling range hydrocarbon productionprocess without a separation step.

The gaseous component separated in the product separator comprisesmostly hydrogen and the carbon dioxide from the decarboxylationreaction. Other components such as carbon monoxide, propane, andhydrogen sulfide or other sulfur containing component may be present aswell. It is desirable to recycle the hydrogen to the isomerization zone,but if the carbon dioxide was not removed, its concentration wouldquickly build up and effect the operation of the isomerization zone. Thecarbon dioxide can be removed from the hydrogen by means well known inthe art such as absorption with an amine, reaction with a hot carbonatesolution, pressure swing absorption, etc. If desired, essentially purecarbon dioxide can be recovered by regenerating the spent absorptionmedia.

Similarly, a sulfur containing component such as hydrogen sulfide may bepresent to maintain the sulfided state of the deoxygenation catalyst orto control the relative amounts of the decarboxylation reaction and thehydrogenation reaction that are both occurring in the deoxygenationzone. The amount of sulfur is generally controlled and so must beremoved before the hydrogen is recycled. The sulfur components may beremoved using techniques such as adsorption with an amine or by causticwash. Of course, depending upon the technique used, the carbon dioxideand sulfur containing components, and other components, may be removedin a single separation step such as a hydrogen selective membrane.

The hydrogen remaining after the removal of at least carbon dioxide maybe recycled to the reaction zone where hydrogenation primarily occursand/or to any subsequent beds/reactors. The recycle stream may beintroduced to the inlet of the reaction zone and/or to any subsequentbeds/reactors. One benefit of the hydrocarbon recycle is to control thetemperature rise across the individual beds. However, as discussedabove, the amount of hydrocarbon recycle may be determined based uponthe desired hydrogen solubility in the reaction zone which is in excessof that used for temperature control. Increasing the hydrogen solubilityin the reaction mixture allows for successful operation at lowerpressures, and thus reduced cost.

The following embodiment is presented in illustration of this inventionand is not intended as an undue limitation on the generally broad scopeof the invention as set forth in the claims. First the one embodiment ofthe process employing the optional isomerization reaction zone isdescribed in general as with reference to FIG. 1. Then the sameembodiment of the process is described in more detail with reference toFIG. 2.

Turning to FIG. 1 renewable feedstock 102 enters deoxygenation reactionzone 104 along with recycle hydrogen 126. Deoxygenated product 106 isstripped in hot hydrogen stripper 108 using hydrogen 114 a. Carbonoxides and water vapor are removed with hydrogen in overhead 110.Stripped deoxygenated product 115 is passed to isomerization zone 116along with recycle hydrogen 126 a and make-up hydrogen 114 b. Isomerizedproduct 118 is combined with overhead 110 and passed to product recoveryzone 120. Carbon oxide stream 128, light ends stream 130, waterbyproduct stream 124, hydrogen stream 126, and branched paraffin-richproduct 122 are removed from product recover zone 120. Hydrogen stream126 is recycled to both the deoxygenation reaction zone 104 andisomerization zone 116. Branched paraffin-rich product 122 is separatedin a stripper 142 to remove an LPG and naphtha stream 144 from a dieselfuel product stream 146. The diesel fuel product stream 146 is collectedfor use as diesel fuel. LPG and naphtha stream 144 is separated incolumn 148 to generate LPG stream 150 and naphtha stream 152. Naphthastream 152 is passed to renewable extraction unit 176 to extractrenewable oil from a source material introduced in line 180. Naphthaenriched in renewable oil is removed from extraction unit 176 in line178. The term enriched means having an increased concentration acomponent after a process step as compared to before a process step. Thestream of naphtha rich in renewable oil 178 may be separated to removethe naphtha and generate the renewable feedstock 102 to the diesel fuelproduction process. The separated naphtha may be recycled to theextraction unit 176. Alternatively, the stream of naphtha rich inrenewable oil 178 may be passed as a mixture without a separation stepto the diesel fuel production process.

Turning to FIG. 2, the process begins with a renewable feedstock stream2 which may pass through an optional feed surge drum. The feedstockstream is combined with recycle stream 16 to form combined feed stream20, which is heat exchanged with reactor effluent and then introducedinto deoxygenation reactor 4. The heat exchange may occur before orafter the recycle is combined with the feed. Deoxygenation reactor 4 maycontain multiple beds shown in FIG. 2 as 4 a, 4 b and 4 c. Deoxygenationreactor 4 contains at least one catalyst capable of catalyzingdecarboxylation and/or hydrodeoxygenation of the feedstock to removeoxygen. Deoxygenation reactor effluent stream 6 containing the productsof the decarboxylation and/or hydrodeoxygenation reactions is removedfrom deoxygenation reactor 4 and heat exchanged with stream 20containing feed to the deoxygenation reactor. Stream 6 comprises aliquid component containing largely normal paraffin hydrocarbons in thediesel boiling range and a gaseous component containing largelyhydrogen, vaporous water, carbon monoxide, carbon dioxide and propane.

Deoxygenation reactor effluent stream 6 is directed to hot high pressurehydrogen stripper 8. Make up hydrogen in line 10 is divided into twoportions, stream 10 a and 10 b. Make up hydrogen in stream 10 a is alsointroduced to hot high pressure hydrogen stripper 8. In hot highpressure hydrogen stripper 8, the gaseous component of deoxygenationreactor effluent 6 is stripped from the liquid component ofdeoxygenation reactor effluent 6 using make-up hydrogen 10 a and recyclehydrogen 28. The gaseous component comprising hydrogen, vaporous water,carbon monoxide, carbon dioxide and possibly some propane, is separatedinto hot high pressure hydrogen stripper overhead stream 14. Theremaining liquid component of deoxygenation reactor effluent 6comprising primarily normal paraffins having a carbon number from about8 to about 24 with a cetane number of about 60 to about 100 is removedas hot high pressure hydrogen stripper bottom 12.

A portion of hot high pressure hydrogen stripper bottoms forms recyclestream 16 and is combined with renewable feedstock stream 2 to createcombined feed 20. Another portion of recycle stream 16, optional stream16 a, may be routed directly to deoxygenation reactor 4 and introducedat interstage locations such as between beds 4 a and 4 b and/or betweenbeds 4 b and 4 c in order, or example, to aid in temperature control.The remainder of hot high pressure hydrogen stripper bottoms in stream12 is combined with hydrogen stream 10 b to form combined stream 18which is routed to isomerization reactor 22. Stream 18 may be heatexchanged with isomerization reactor effluent 24.

The product of the isomerization reactor containing a gaseous portion ofhydrogen and propane and a branched-paraffin-rich liquid portion isremoved in line 24, and after optional heat exchange with stream 18, isintroduced into hydrogen separator 26. The overhead stream 28 fromhydrogen separator 26 contains primarily hydrogen which may be recycledback to hot high pressure hydrogen stripper 8. Bottom stream 30 fromhydrogen separator 26 is air cooled using air cooler 32 and introducedinto product separator 34. In product separator 34 the gaseous portionof the stream comprising hydrogen, carbon monoxide, hydrogen sulfide,carbon dioxide and propane are removed in stream 36 while the liquidhydrocarbon portion of the stream is removed in stream 38. A waterbyproduct stream 40 may also be removed from product separator 34.Stream 38 is introduced to product stripper 42 where components havinghigher relative volatilities are separated into stream 44 with theremainder, the diesel boiling range components, being withdrawn fromproduct stripper 42 in line 46. Stream 44 is introduced intofractionator 48 which operates to separate LPG into overhead 50 leavinga naphtha bottoms 52. Naphtha in stream 52 is passed to an oilextraction unit 76 of an oil processing operation. Naphtha bottoms 52 isused as the extraction solvent in extraction unit 76. The triglycerideenriched naphtha is removed from oil extraction unit 76 in line 78. Thenaphtha may be separated from the oil and the oil used as the renewablefeedstock.

The vapor stream 36 from product separator 34 contains the gaseousportion of the isomerization effluent which comprises at least hydrogen,carbon monoxide, hydrogen sulfide, carbon dioxide and propane and isdirected to a system of amine absorbers to separate carbon dioxide andhydrogen sulfide from the vapor stream. Because of the cost of hydrogen,it is desirable to recycle the hydrogen to deoxygenation reactor 4, butit is not desirable to circulate the carbon dioxide or an excess ofsulfur containing components. In order to separate sulfur containingcomponents and carbon dioxide from the hydrogen, vapor stream 36 ispassed through a system of at least two amine absorbers, also calledscrubbers, starting with the first amine absorber zone 56. The aminechosen to be employed in first amine scrubber 56 is capable ofselectively removing at least both the components of interest, carbondioxide and the sulfur components such as hydrogen sulfide. Suitableamines are available from DOW and from BASF, and in one embodiment theamines are a promoted or activated methyldiethanolamine (MDEA). See U.S.Pat. No. 6,337,059, hereby incorporated by reference in its entirety.Suitable amines for the first amine absorber zone from DOW include theUCARSOL™ AP series solvents such as AP802, AP804, AP806, AP810 andAP814. The carbon dioxide and hydrogen sulfide are absorbed by the aminewhile the hydrogen passes through first amine scrubber zone and intoline 68 to be recycled to the first reaction zone. The amine isregenerated and the carbon dioxide and hydrogen sulfide are released andremoved in line 62. Within the first amine absorber zone, regeneratedamine may be recycled for use again. The released carbon dioxide andhydrogen sulfide in line 62 are passed through second amine scrubberzone 58 which contains an amine selective to hydrogen sulfide, but notselective to carbon dioxide. Again, suitable amines are available fromDOW and from BASF, and in one embodiment the amines are a promoted oractivated MDEA. Suitable amines for the second amine absorber zone fromDOW include the UCARSOL™ HS series solvents such as HS101, HS 102,HS103, HS104, HS115. Therefore the carbon dioxide passes through secondamine scrubber zone 58 and into line 66. The amine may be regeneratedwhich releases the hydrogen sulfide into line 60. Regenerated amine isthen reused.

Other separation systems are possible, such as adsorbents and treatingprocesses. However, the amine absorber zone system of FIG. 2 has severaladvantages with cost being a primary advantage. Amine absorber systemsare less costly than molecular sieve adsorbents or treating processes.Vapor stream 36 has a total volume that is much greater than thecombined volume of carbon dioxide and hydrogen sulfide. Typically, theamount of hydrogen sulfide in vapor stream 36 ranges from about 1 toabout 5 mass-%. In the configuration shown in FIG. 2, the first amineabsorber zone 56 is sized to accommodate the flow of the entire vaporstream 36. However, the second amine absorber zone 58 is greatly reducedin size as compared to the first since the flow of material to thesecond amine absorber zone is only a fraction of vapor stream 36. Thereduction in the size of the second amine absorber zone allows forreduced capital and operating costs.

1. An integrated process for producing a paraffin-rich diesel boilingrange product from a renewable feedstock and for extracting renewableoil from a source material comprising: a) treating the renewablefeedstock in a first reaction zone by hydrogenating and deoxygenatingthe feedstock using a catalyst at reaction conditions in the presence ofhydrogen to provide a first reaction zone product stream comprisinghydrogen, carbon dioxide, and paraffins having from about 8 to about 24carbon atoms; b) separating the first reaction zone product stream toform: i) a stream comprising hydrogen and carbon dioxide; ii) a streamcomprising the paraffins; and iii) a water stream c) separating thestream comprising paraffins into a diesel product stream and a naphthaand LPG stream; d) separating the naphtha and LPG stream into a naphthastream and an LPG stream; and e) passing the naphtha stream to arenewable oil extraction unit and extracting a renewable oil from asource material using the naphtha stream as an extraction solvent. 2.The process of claim 1 further comprising passing the renewable oil as amixture with the extraction solvent to the first reaction zone.
 3. Theprocess of claim 1 further comprising removing a renewable oil-enrichednaphtha stream from the oil extraction unit wherein the oil-enrichednaphtha stream is the renewable feedstock.
 4. The process of claim 1further comprising removing a renewable oil-enriched naphtha stream fromthe oil extraction unit, and separating the naphtha from the renewableoil to generate the renewable feedstock.
 5. The process of claim 4further comprising recycling the separated naphtha to the renewable oilextraction unit.
 6. The process of claim 1 further comprising recyclinga portion of the stream comprising paraffins to the first reaction zoneat a volume ratio of recycle to feedstock in the range of about 2:1 toabout 8:1.
 7. The process of claim 1 wherein the reaction conditions inthe first reaction zone include a temperature of about 40° C. to about400° C. and a pressure of about 689 kPa absolute (100 psia) to about13,790 kPa absolute (2000 psia).
 8. The process of claim 1 furthercomprising separating carbon dioxide from the stream comprising hydrogenand carbon dioxide and recycling the remaining hydrogen to the firstreaction zone.
 9. The process of claim 1 further comprising treating apetroleum derived hydrocarbon in the first reaction zone with therenewable feedstock.
 10. The process of claim 1 wherein the treating ofthe feedstock in the first reaction zone is additionally in the presenceof at least one sulfur-containing component and the process furthercomprising separating the carbon dioxide and the sulfur-component fromthe stream comprising hydrogen and carbon dioxide and recycling theremaining hydrogen to the first reaction zone.
 11. An integrated processfor producing a branched paraffin-rich diesel product from a renewablefeedstock and for extracting renewable oil from a source materialcomprising; a) treating the feedstock in a first reaction zone byhydrogenating and deoxygenating the feedstock using a catalyst atreaction conditions in the presence of hydrogen to provide a firstreaction zone product stream comprising hydrogen, water, carbon dioxide,and n-paraffins having from about 8 to about 24 carbon atoms; b)separating, in a hot high pressure hydrogen stripper, a gaseous streamcomprising hydrogen and at least a portion of the water and carbondioxide from the first reaction zone product stream and introducing aremainder stream comprising at least the n-paraffins to a secondreaction zone to contact an isomerization catalyst at isomerizationconditions to isomerize at least a portion of the n-paraffins andgenerate a branched paraffin-rich stream; c) separating a combination ofthe branched paraffin-rich stream and the gaseous stream to form: i) astream comprising hydrogen and carbon dioxide; ii) a stream comprisingbranched paraffins, LPG, and naphtha; and iii) a water stream; d)separating the stream comprising branched paraffins, LPG, and naphthainto a diesel product stream and a naphtha and LPG stream; e) separatingthe naphtha and LPG stream into a naphtha stream and an LPG stream; andf) passing the naphtha stream to a renewable oil extraction unit andextracting a renewable oil from a source material using the naphthastream as an extraction solvent.
 12. The process of claim 11 furthercomprising passing the renewable oil as a mixture with the extractionsolvent to the first reaction zone.
 13. The process of claim 11 furthercomprising removing a renewable oil-enriched naphtha stream from the oilextraction unit wherein the oil-enriched naphtha stream is the renewablefeedstock.
 14. The process of claim 11 further comprising removing arenewable oil-enriched naphtha stream from the oil extraction unit, andseparating the naphtha from the renewable oil to generate the renewablefeedstock.
 15. The process of claim 14 further comprising recycling theseparated naphtha to the oil extraction unit.
 16. The process of claim11 further comprising recycling at least a portion of the branchedparaffin-rich stream to the second reaction zone.
 17. The process ofclaim 11 wherein the isomerization conditions in the second reactionzone include a temperature of about 40° C. to about 400° C. and apressure of about 689 kPa absolute (100 psia) to about 13,790 kPaabsolute (2000 psia).
 18. The process of claim 11 wherein the hot highpressure hydrogen stripper is operated at a temperature of about 40° C.to about 300° C. and a pressure of about 689 kPa absolute (100 psia) toabout 11,790 kPa absolute (2000 psia).
 19. The process of claim 11wherein the second reaction zone is operated at a pressure at least 345kPa absolute (50 psia) greater than that of the first reaction zone. 20.The process of claim 11 further comprising treating a petroleum derivedhydrocarbon in the first reaction zone with the renewable feedstock.